Schlumberger Technology Corporation

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Kais Gzara

Vikas Jain

Chanh Cao Minh

Roger Griffiths

Iain M Rezmer-Cooper

Jean-Michel Hache

Kamal Babour

Iain Michael Cooper

Nicholas J Heaton

Dean M Willberg

Michael Wilt

Denis Heliot

Jean Desroches

Christian Besson

Mark W Hutchinson

Ahmed El-Banbi

Alan Patrick Hibler

Patrick A Hibler

A method for estimation of water properties and hydrocarbon properties in a subsurface formation include acquiring a plurality of well log measurements from the subsurface formation. The water properties and the formation properties are parameterized with respect to a selected set of well log measurements. The parameterized water properties, the parameterized formation properties and the well log measurements are graphically displayed to estimate the water properties.

Determination of formation properties using graphical methods

A method for determining a volume of a constituent(s) in a geological formation may include generating an equation of state based upon log measurements for the geological formation, with the equation of state providing a correlation between the log measurements, determining a quality factor for the equation of state, and for each of a plurality of different constituents expected to be in the formation, determining a constituent compliance factor for each of the constituents. The method may further include determining an uncertainty for each constituent compliance factor, determining a likelihood that each constituent is present in the formation based upon the quality factor, the constituent compliance factor for the constituent, and the uncertainty for the constituent compliance factor, generating a volumetric model based upon the log measurements and the determined likelihoods of the constituents in the formation, and determining the volume of the constituent(s) based upon the volumetric model.

Formation evaluation using stochastic analysis of log data

A method for generating a model of a formation property includes acquiring a formation property measurement. A petrophysical quantity is inverted from the formation property measurement. A model is generated based on the inverted petrophysical quantity.

Petrophysical relationships using blind source separation techniques

A method for determining volumetric data for fluid within a geological formation is provided. The method includes collecting first and second dataset snapshots of the geological formation based upon measurements from the borehole at respective different first and second times and generating a differential dataset based upon the first and second dataset snapshots. Multiple points are determined within the differential dataset, including a first point representing a first displaced fluid, a second point representing a second displaced fluid, and an injected fluid point that corresponds to properties of the injected fluid. A further third point is determined based on at least one other property of the displaced fluid, and a volumetric composition of the displaced fluids is determined based upon the differential dataset, the first point, and second point, and third point.

Formation volumetric evaluation using normalized differential data

A method for analyzing at least one characteristic of a geological formation may include obtaining measured data for the geological formation based upon a logging tool. Measured data may come from multiple passes or multiple depths of investigation. The method may further include generating a kernel describing a known linear mapping between the measured data and unknown data points representing at least one characteristic of the geological formation, and a redundant dictionary including a plurality of different basis functions expected to span the solution space of the unknown data points. The unknown data points representing the at least one characteristic of the geological formation may be determined from the measured data, the kernel and the redundant dictionary based upon an Lminimization.

Methods to characterize formation properties

A method of interpreting petrophysical measurement data include arranging measurements of at least one physical property of formations into a matrix representing the measurements and selecting a range of number of unobserved factors or latent variables for factor analysis. Factor analysis is performed on the measurement matrix and comprises performing factorization of measurements matrix into a number of factorsand performing rotation of the factorization results. Whether the factor loadings for each factor have achieved a 'simple structure' is determined and either each of the selected number of factors is associated with a physical parameter of the formations, or one is added to the number of factors and factor analysis and rotation are repeated until factor loadings of all factors have achieved 'simple structure' such that the each of the number of factors is associated with a physical property of the formations.

Identifying formation, matrix and fluid related characteristics from subsurface data using factor analysis

An apparatus and a method for characterizing parts of a reservoir surrounding a borehole are provided including using at least one transmitter to emit a probing signal into the borehole and at least one receiver to receive a signal representing a response of the formation to the probing signal, with the distance separating the transmitter and the receiver being variable while suspended in the borehole using for example an apparatus which can be decoupled in the borehole into a stationary and a mobile section, carrying transmitter and receiver.

Single well reservoir characterization apparatus and methods

Hydraulic fracture dimensions and, optionally, fracture closure pressure and time are determined by adding particulate matter that discharges to create an acoustic signal to the proppant, allowing the particulate matter to discharge, and detecting the acoustic signal with geophones or accelerometers. The particulate matter may be spheres or fibers. The discharge may be explosion, implosion, detonation, or rapid combustion or ignition. The discharge may be triggered by fracture closure or by chemical reaction.

Mapping fracture dimensions

A method comprising determining a characteristic of a mud mixture surrounding a drilling tool within an inclined borehole in which a drilling tool is conveyed. The method includes defining a cross-section of the tool which is orthogonal to a longitudinal axis of the tool. A bottom contact point of the cross-section of the tool is determined, which contacts the inclined borehole as the tool rotates in the borehole. The cross-section is separated into at least two segments, where one of the segments is called a bottom segment of the borehole which includes the bottom contact point of the cross-section of the tool with the inclined borehole. The tool is turned in the borehole. Energy is applied into the borehole from an energy source disposed in the tool, as the tool is turning in the borehole. Measurement signals are received at a sensor disposed in the tool from circumferentially spaced locations around the borehole, where the measurement signals are in response to returning energy which results from the interaction of the applied energy with the mud mixture and the formation. The measurement signals are associated with a particular segment during the time such signals are produced in response to energy returning from the mud mixture and the formation as the tool is turning in the borehole. An indication of a characteristic of the mud mixture is derived as a function of the measurement signals associated with a plurality of the at least two segments of the borehole. The indications of a characteristic of the mud mixture for the plurality of segments are compared with at least one of each other and a known indication of a characteristic of the mud mixture.

Method of kick detection and cuttings bed buildup detection using a drilling tool

In a drilling system for drilling a well borehole from a surface location, hydraulic calibration is performed by making a plurality of hydraulic calibration measurements, each hydraulic calibration measurement being made at a respective drill-string RPM and flow-rate within a hydraulic calibration range. A hydraulic baseline function is then determined which predicts, within a predetermined degree of accuracy, each of the plurality of hydraulic calibration measurements.

Hydraulic calibration of equivalent density

The present invention presents a method that effectively restores the real-time advantage of annular pressure while drilling (APWD) measurements taken during certain drilling operations that require the mud circulation pumps to be turned off (a &ldquo;pumps-off&rdquo; condition). APWD data, such as pressure measurements, is obtained from instruments and related electronics within the BHA. APWD data can be measured, stored and even processed in the BHA during a pumps-off condition for subsequent processing or communication of a reduced amount of data to the driller at the surface.

Method for obtaining leak-off test and formation integrity test profiles from limited downhole pressure measurements

The present invention presents a method that effectively provides the near real-time advantage of annular pressure while drilling (APWD) measurements taken during pipe connections that require the mud circulation pumps to be turned off (a &ldquo;pumps-off&rdquo; condition). APWD data, such as pressure measurements, are obtained from instruments and related electronics within the bottom-hole assembly (BHA). APWD data can be measured, stored and even processed in the BHA during a pumps-off condition for subsequent processing or communication of a reduced amount of data to the driller at the surface.

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Tunis, Tunisia

Kais Gzara